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EP2118997B1 - Procédé de fonctionnement d'une centrale électrique - Google Patents

Procédé de fonctionnement d'une centrale électrique Download PDF

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Publication number
EP2118997B1
EP2118997B1 EP08708869A EP08708869A EP2118997B1 EP 2118997 B1 EP2118997 B1 EP 2118997B1 EP 08708869 A EP08708869 A EP 08708869A EP 08708869 A EP08708869 A EP 08708869A EP 2118997 B1 EP2118997 B1 EP 2118997B1
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EP
European Patent Office
Prior art keywords
frequency
gas turbine
grid
speed
event
Prior art date
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Active
Application number
EP08708869A
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German (de)
English (en)
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EP2118997A1 (fr
Inventor
Jürgen Hoffmann
Thomas Meindl
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GE Vernova GmbH
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Alstom Technology AG
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Publication of EP2118997A1 publication Critical patent/EP2118997A1/fr
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    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01D—NON-POSITIVE DISPLACEMENT MACHINES OR ENGINES, e.g. STEAM TURBINES
    • F01D15/00—Adaptations of machines or engines for special use; Combinations of engines with devices driven thereby
    • F01D15/10—Adaptations for driving, or combinations with, electric generators
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
    • F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
    • F02C9/00—Controlling gas-turbine plants; Controlling fuel supply in air- breathing jet-propulsion plants
    • F02C9/26—Control of fuel supply
    • F02C9/28—Regulating systems responsive to plant or ambient parameters, e.g. temperature, pressure, rotor speed
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02P—CONTROL OR REGULATION OF ELECTRIC MOTORS, ELECTRIC GENERATORS OR DYNAMO-ELECTRIC CONVERTERS; CONTROLLING TRANSFORMERS, REACTORS OR CHOKE COILS
    • H02P9/00—Arrangements for controlling electric generators for the purpose of obtaining a desired output
    • H02P9/10—Control effected upon generator excitation circuit to reduce harmful effects of overloads or transients, e.g. sudden application of load, sudden removal of load, sudden change of load
    • H02P9/105—Control effected upon generator excitation circuit to reduce harmful effects of overloads or transients, e.g. sudden application of load, sudden removal of load, sudden change of load for increasing the stability
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02P—CONTROL OR REGULATION OF ELECTRIC MOTORS, ELECTRIC GENERATORS OR DYNAMO-ELECTRIC CONVERTERS; CONTROLLING TRANSFORMERS, REACTORS OR CHOKE COILS
    • H02P9/00—Arrangements for controlling electric generators for the purpose of obtaining a desired output
    • H02P9/10—Control effected upon generator excitation circuit to reduce harmful effects of overloads or transients, e.g. sudden application of load, sudden removal of load, sudden change of load
    • H02P9/107—Control effected upon generator excitation circuit to reduce harmful effects of overloads or transients, e.g. sudden application of load, sudden removal of load, sudden change of load for limiting effects of overloads

Definitions

  • the present invention relates to the field of power plant technology. It relates to a method for operating a power plant according to the preamble of claim 1.
  • Fig. 1 shows in a highly simplified representation of a power plant 10 'of known type, the power generated by means of a gas turbine 12 with coupled generator 18 and fed into a network 21.
  • the gas turbine 12 and the generator 18 are connected by a common shaft 19 and form a 1-shaft turbine train 11.
  • the gas turbine comprises in the simplest case a compressor 13, which sucks and compresses combustion air via an air inlet 16.
  • the compressor 13 may be composed of a plurality of partial compressors connected in series, which operate on rising pressure level and possibly allow an intermediate cooling of the compressed air.
  • the compressed in the compressor 13 combustion air enters a combustion chamber 15, in which via a fuel supply 17 liquid (eg oil) or gaseous (eg natural gas) injected fuel and burned by consuming combustion air.
  • liquid eg oil
  • gaseous eg natural gas
  • the emerging from the combustion chamber 15 hot gases are relaxed in a subsequent turbine 14 under work and thus drive the compressor 13 and the flanged generator 18 at.
  • the exhaust gas still relatively hot at the exit from the turbine can additionally be sent through a downstream heat recovery steam generator 23 in order to generate steam for the operation of a steam turbine 24 in a separate water-steam cycle 25.
  • Such a combination is called a combined cycle power plant.
  • the steam turbine 24 may be coupled to the generator 18 on the opposite side of the turbine 14. But you can also drive your own generator.
  • the speed of the gas turbine 12 is in a fixed ratio to the generated in the generator 18 frequency of the AC voltage, which must be equal to the network frequency of the network 21.
  • the generator frequency or mains frequency of 60 Hz is a gas turbine speed of 3600 rpm (eg gas turbine GT24 of the Applicant) and the generator frequency of 50 Hz a speed of 3000 rpm (eg gas turbine GT26 of the Applicant) assigned.
  • a mechanical transmission 26 are inserted, which is usually designed as a reduction gear and thus higher speeds and smaller designs of the gas turbine 12 allows
  • 26 can only be used for outputs of up to about 130 MW, while on the other hand, the large outputs per gas turbine of more than 100 MW and the high efficiencies are achieved, especially with comparatively slowly rotating single-shaft machines.
  • the shaft train of the power plant system is greatly accelerated or decelerated. During this acceleration, a large amount of energy is stored or released. With this energy intake or release, the power plant supports the grid frequency for the first moment by the moment of inertia of the shaft.
  • the US 2004/0264089 describes a power generation system that detects irregularities in a network and can disconnect a turbo-generator from this network without damage.
  • the object is solved by the entirety of the features of claim 1.
  • Essential for the inventive method is that when short-term overfrequency or underfrequency events occur in the network, the mechanical Speed of the gas turbine can be controlled independently of the mains frequency. Underfrequency of the network, the speed of the gas turbine can be lowered more or less than the grid frequency, and be raised more or less than the grid frequency at overfrequency of the network. As a result, the frequency support is increased by releasing or receiving rotational energy from the shaft train of the gas turbine.
  • Under short-term power frequency changes here are network frequency changes that occur within a few seconds or a few dozen seconds, as caused for example by the trip of a power plant or connecting a large consumer understood. As a rule, short-term changes are understood to mean periods of a few seconds to about 30 seconds.
  • the speed reduction or - raising the gas turbine is controlled. Since the speed reduction is controlled, a suitable feedforward control can minimize the transient overshoot and undershoot in the hot gas temperature.
  • a gas turbine with a power greater than 100 MW and a frequency converter in the form of a matrix converter are used as the electronic decoupling device.
  • the operating frequency differs significantly from the mains frequency or second operating frequency, wherein in particular the mains frequency or the operating frequency is 50 Hz or 60 Hz.
  • the mains frequency or the operating frequency is 50 Hz or 60 Hz.
  • General are for this configuration as a clear distinction to provide deviations of more than 5% between mains and operating frequency.
  • 50 Hz gas turbines in 60 Hz grids and vice versa differences in the order of 20% are to be expected.
  • the deviation can also be well over 100%.
  • a gas turbine with sequential combustion is also used as a gas turbine.
  • the matrix converter used comprises a plurality of controllable bidirectional switches arranged in an (mxn) matrix and controlled by a controller m optionally connect inputs to n outputs, where m is greater than n, and wherein first means for Determining the signs of the currents in the inputs and second means for determining the signs of the voltages between the inputs are provided, and wherein the first and second means are in operative connection with the controller.
  • Bidirectional switches can consist of one component but can also be constructed of several components. For example, two antiparallel thyristors with the opposite switching direction can be used as controllable bidirectional switches.
  • the means for determining the signs of currents and voltage can be current or voltage meters, for example. Alternatively, z. As well as binary encoder that spend only the sign applicable.
  • a power plant with gas turbine and an electronic decoupling device is reproduced in a simplified schematic diagram, as it is suitable for carrying out the inventive method.
  • the power plant 10 comprises a gas turbine 12 with a compressor 13 and sequential combustion, in which a first combustion chamber 15 with a first fuel via a first fuel supply 17 generates hot gas, which is expanded in a first turbine 14a, then passed into a second combustion chamber 15 ' is where it causes a second fuel via a second fuel supply 17 ', a reheating of the hot gas, which is then expanded in the second turbine 14 b.
  • the sequential combustion which is particularly advantageous in terms of efficiency, it is also possible to provide single-stage combustion.
  • the remaining parts of the system correspond to the parts with the same reference number in the Fig. 1 or 2 ,
  • the generator 18 is flanged directly to the shaft 19 of the gas turbine 12. Thus, the generator 18 rotates at the same speed as the gas turbine 12. Between the output of the generator 18 and the network 21 but now an electronic decoupling device 17 is arranged, which decouples the In the generator 18 generated operating frequency or the speed of the gas turbine 12 causes the predetermined power frequency of the network.
  • the electronic decoupling device 27 is - in order to limit the power loss - preferably designed as a matrix converter without DC intermediate circuit.
  • a matrix converter which operates due to its control particularly low loss, is in the EP-A2-1 199 794 been described in the structure and in the mode of action.
  • Other versions of such a matrix converter are in the EP-A1-1 561 273 , in the DE-A1-10 2004 016 453 , of the DE-A1-10 2004 016 463 and the DE-A1-10 2004 016 464 been made.
  • Fig. 4 the schematic diagram of a matrix converter with 6 input phases and 3 output phases is shown.
  • the matrix converter (27) connects in a time sequence 6 phases G1, .., G6 of a generator 18 as a source with 3 phases L1, .., L3 of a load 30.
  • the power unit 29 required for this purpose comprises 18 bidirectional switches 32 in the form of anti-parallel switched thyristors (in the general case there are mxn switches for m input / source phases and n output / load phases).
  • the switches 32 are arranged in a (6 x 3) matrix.
  • a controller or a controller 31 is provided which receives from a timer 28 time signals (a clock frequency).
  • the switching state of the switches 32 (ON, OFF) is monitored and reported in each case via a first signal line 36 to the controller 31.
  • the switches 32 are each controlled by the controller 31 via a control line 35.
  • the power plant In the event of frequency dips, the power plant must be able to maintain the power delivered at normal grid frequency, or ideally even provide increased power to the grid. Previous power plant systems can only do this in one ensure limited size.
  • the mains frequency reduction senses a system permanently linked to the mains frequency as undesirable speed reduction on the turbine and the generator. At the same time, the output power drops with otherwise identical operating parameters.
  • a gas turbine system reacts in this case with a significantly increased fuel supply, which leads to an increased hot gas temperature within the turbine.
  • Another positive aspect of a grid frequency independent power plant system is the better adaptability of a plant to different site conditions.
  • the already mentioned grid stability is an essential aspect, which depends decisively on the location.
  • environmental conditions such as outside temperatures, air pressure, in particular the conditional by the altitude altitude, air humidity, and fuel composition, which affect the operating state of a power plant.
  • the additional degree of freedom of the mains frequency-independent speed control makes it possible to generate optimized operating conditions in accordance with the current environmental conditions. Both efficiency improvements and performance increases are possible.
  • the gas turbine is in all operating ranges, regardless of the mains frequency or operating frequency of the consumer as close as possible to the aerodynamic design speed operated to optimize the performance, ie efficiency and performance.
  • Fig. 5 a simplified scheme of a power plant 10 is shown, which is designed for an operating method according to the invention.
  • the turbine train 11 with the gas turbine 12 and the generator 18 correspond to those in Fig. 4 , This also applies to the electronic decoupling device 27 and the connected network 21.
  • the network 21 may be a general supply network, but also a traction current network. On the representation of a possible additional steam turbine with a corresponding water / steam cycle has been omitted here for reasons of space.
  • the gas turbine 12 For controlling or controlling the gas turbine 12 serve at least one row adjustable compressor guide vanes 42 at the input of the compressor 13 and control valves 40 and 41 in the fuel supply 17 and 17 'to the combustion chambers 15, 15'.
  • the corresponding control signals come from a controller 39 according to certain input parameters that can be used individually or in selectable combination.
  • One possible parameter is the compressor inlet temperature, which is measured with a first sensor 43 arranged at the air inlet 16.
  • Other possible parameters are the compressor end temperature and the compressor discharge pressure, which are measured with second and third transducers 44 and 45, respectively, at the output of the compressor.
  • Another transducer 46 the at a cooling air supply 50 from the compressor 13 to thermally loaded components of the Gas turbine 12, for example, in the two turbines 14a and 14b, is arranged, measures the pressure and / or temperature and / or the flow rate of the cooling air.
  • Another transducer 47 may be disposed on the second combustion chamber 15 'to measure the pressure in this combustion chamber.
  • the speed of the gas turbine 12 can be removed, for example, at the generator 18 and entered via a measuring line 48 in the control 39.
  • a Netzfrequenzaufêt 49 may be provided for measuring the network frequency in the network 21, a Netzfrequenzaufêt 49 may be provided.
  • the controller 39 can then regulate the aerodynamic or mechanical speed of the gas turbine 12 to a constant value, without the speed being influenced in any other way by the grid frequency F of the network 21.
  • the regulation of the gas turbine speed can be carried out with complete decoupling of the gas turbine 12 from the network 21 to the gas turbine 12 via appropriate parameters, such as fuel mass flow and position of Ver Whyrvorleit Research.
  • the regulation of the rotational speed can alternatively be carried out, for example, by the fact that the setpoint speed 51 calculated in the control unit 39 of the gas turbine is transmitted to the controller 31 of the decoupling device 27 and the speed is imposed on the gas turbine 12 via the generator.
  • the generator 18 is supported through the decoupling device 27 thereby against the quasi-static in comparison to the gas turbine 12 network 21 and forces by controlling the frequency ratio between the network F and mechanical rotation speed n mech of the gas turbine, the rotational speed n mech on.
  • the decoupling device 27 operates in this case as a variable transmission with controlled transmission ratio between the mechanical speed of the gas turbine n mech and mains frequency F.
  • FIG. 6 to FIG. 10 exemplified by underfrequency events. They are described for a 50 Hz network 21, but are analogously applicable to a 60 Hz network 21 or a network 21 with a different design frequency. By analogy, the corresponding concepts for overfrequency events will be apparent to those skilled in the art. Noise, high-frequency small variations of the line frequency F or noise are neglected and not shown.
  • Deadband and sliding Mean also called average supply network frequency
  • the EP0858153 and their application to gas turbines 12 with electronic decoupling to the network 21 are part of this application.
  • Fig. 6 schematically shows the course of the gas turbine speed n mech , as well as the output from the gas turbine shaft train to the network dynamic power P dyn during an underfrequency event.
  • the line frequency F drops from 50 Hz to 49 Hz with a constant gradient between the times T 2 and T 3 .
  • the dynamic speed P dyn which is proportional to the gradient of the speed change, is output during the speed change.
  • the influence of the ratio between the mains frequency change and the gas turbine speed change on an underfrequency event given a predetermined change in the mains frequency, which is represented here as a standardized mains frequency f G will be explained with reference to 3 ratios.
  • the speed with a ratio of 2: 1 is more concentrated than the grid frequency f G. Accordingly, the double dynamic power P dyn, 2 can be delivered. However, a doubling of the mechanical speed n mech, 3 must be accepted.
  • the speed is subtracted at a ratio of 1: 2 weaker than the grid frequency f G. Accordingly, only half the dynamic power P dyn, 3 can be delivered. The mechanical speed n mech, 3 is lowered but only half as much.
  • Fig. 7 schematically the influence of the ratio between mains frequency change and gas turbine speed change electronic decoupling is shown in an anticipated underfrequency event.
  • the first case is again shown, in which the speed change of the shaft train n mech, 1 follows exactly the change of the normalized network frequency f G and thus during the transit between the time T 2 and T 3 to deliver the dynamic power P dyn, 1 leads.
  • the operator is notified of an impending event, such as the shutdown of a larger power plant from the grid, or the connection of a larger load to the grid, which may cause a frequency dip. Accordingly, it selects a standby mode of the gas turbine at time T 0 .
  • the mechanical speed n mech of the gas turbine now increases and reaches an increased mechanical speed n mech at time T 1 . Accordingly, dynamic power P dyn is received from the shaft train (not shown).
  • the mechanical speed n mech, 4 of the gas turbine 12 is first increased by 1% between T 0 and T 1 .
  • the rotational speed n mech, 4 of the gas turbine shaft train with a ratio of 1: 2 is weaker than the grid frequency f G. Accordingly, only half the dynamic power P dyn, 4 can be delivered.
  • the mechanical speed n mech, 4 is lowered only half as much and at the end of the grid frequency collapse, the gas turbine 12 still drives at design speed.
  • the mechanical speed n mech, 5 of the gas turbine is first increased by 2% between T 0 and T 1 .
  • the speed of the gas turbine shaft train with a ratio of 2: 1 is squeezed more than the grid frequency f G during the power frequency break-in between T 2 and T 3 . Accordingly, the double dynamic power P dyn, 5 can be delivered.
  • the mechanical speed n mech, 5 is also twice as much lowered. Due to the increased speed before the Netzfrequenzeinbruche the gas turbine but at the end of the power-line collapse still drives at the same speed n mech , as in the reference case with fixed coupling between the network 21 and gas turbine 12th
  • Fig. 8 First, an example of an underfrequency event with a fixed coupling between the gas turbine 12 and the network 21 is shown schematically.
  • a frequency decline occurs between time T 2 and T 3 .
  • the mains frequency F decreases from 50 Hz to 49 Hz.
  • the mechanical speed n mech falls from 100% to 98%.
  • Proportional to the speed decreases the Ansaugmassenstrom the gas turbine 12 (not shown), resulting in initially constant fuel mass flow (also not shown) to an increase in the hot gas temperature T hot .
  • the power loss at the first moment is small due to the increase of the hot gas temperature T hot .
  • the control unit 39 of the gas turbine 12 tries to counteract the steep rise in the hot gas temperature T hot . In reality, this leads depending on the transient course of the underfrequency event, the speed of the measuring chains and the time constant of the control 39 to undershoot the hot gas temperature T hot .
  • the minimum hot gas temperature T hot is reached in this example at time T 3 .
  • the grid frequency F stabilized at 49 Hz here.
  • the gas turbine power P rel undergoes a significant slump. Only at a delay does the controller at time T 4 bring the hot- gas temperature T hot to the nominal value raised for frequency assistance with respect to the design value.
  • the minimum in the hot gas temperature T hot is reached in the example purely coincidentally at the time T 3 .
  • Fig. 8a the history of the gas turbine speed n mech of the example is from a fixed frequency underfrequency event between the gas turbine 12 and the network 21 Fig. 8 shown again.
  • the associated normalized dynamic power P dyn is shown schematically over time. In accordance with the course of the frequency change, a maximum in the dynamic power P dyn results at the time of the steepest speed gradient .
  • the illustrated normalized dynamic power P dyn is normalized with this maximum value.
  • this maximum may be the order of magnitude of the full power output of the gas turbine 12 to reach. Accordingly, the power plant, in particular the shaft train of the gas turbine 12 and the electrical systems, interpreted.
  • Fig. 8b For comparison, it is shown how, with a constant gradient in the mechanical speed n mech, the same kinetic energy is emitted in the period between T 2 and T 3 , as in the example Fig. 8a , However, the dynamic power P dyn becomes 60% of the maximum value of the example Fig. 8a limited. Accordingly, power plant can be designed with a decoupling and regulated or limited speed gradient to lower maxima. When operating with a constant from the network 21 independent gas turbine speed n mech can be dispensed with the design for dynamic power P dyn .
  • the control 39 can approximately predict changes in the Ansaugmassenstromes and the boundary conditions of the combustion chamber 15, 15 * and accordingly a pilot control of the control valves 17, 17 * make.
  • the transient behavior can be improved and avoid or reduce maxima in the hot gas temperature.
  • Fig. 9 is analogous to Fig. 8 the same underfrequency event with electronic decoupling and constant gas turbine speed shown schematically.
  • the mechanical speed of the gas turbine n mech remains constant regardless of the grid frequency F. Accordingly, no direct influence of the grid frequency F on the hot gas temperature T hot and the gas turbine power P rel at time T 2 can be seen. Only with a short delay, the control 39 raises the hot gas temperature T hot to increase the gas turbine power P rel for frequency support.
  • the grid frequency F stabilized at the time T 3 to 49 Hz. Due to the inertia of the gas turbine 12, the measurements and the control 39, the gas turbine 12 comes to the time T 4 only with a small time delay a quasi-stationary operation with constant power P rel and hot gas temperature T hot .
  • FIG. 10 schematically shown an underfrequency event with electronic decoupling, anticipated underfrequency event and during the frequency collapse constant held gas turbine speed n mech .
  • the operator is notified of an impending event, such as the shutdown of a larger power plant from the grid 21, or the connection of a larger load to the grid 21, which may cause a frequency dip. Accordingly, it selects a standby mode of the gas turbine 12 at the time T 0 .
  • the mechanical speed n mech of the gas turbine now increases and reaches, for example, 101% at time T 1 .
  • the hot gas temperature T hot is reduced in accordance with the increased rotational speed n mech .
  • the gas turbine 12 can further n on the increased speed to be operated mech.
  • the hot gas temperature T hot product may be increased to improve performance to the full-load value.
  • the gas turbine 12 is operated at design hot gas temperature at an increased speed n mech and, in this example for frequency assistance, can deliver a normalized power lying above the full load power. This is just under 101% in this example. This can be done without the otherwise customary acceptance of life-cycle losses will be realized for frequency support.
  • Analog driving concepts are conceivable for gas turbines with sequential combustion. In principle, it is possible to use the hot gas temperatures T hot of both combustion chambers 15, 15 'for regulation or to change only the hot gas temperature T hot of a combustion chamber 15, 15'. The combinations with other parameters are also provided here depending on the driving concept and operating point.
  • the ratios of the influences of speed n mech and hot gas temperature T hot on the gas turbine power P rel, and the dynamic flow of the control are highly dependent on the design of the gas turbine 12 and the implemented control 39 and the control parameters.
  • the effect of the hot gas temperature T hot of a second combustion chamber 15 'in a sequential combustion gas turbine 12 is significantly higher than the influence of a first combustion chamber 15.
  • the driving concept of the gas turbine 12 can be optimized according to the exemplary embodiments shown.
  • the driving concepts are not limited to the illustrated examples, but can be combined and expanded by the skilled person according to the requirements.
  • the gas turbine speed n mech may be advantageous to first change the gas turbine speed n mech with a speed gradient that is higher than that of the mains frequency change. Since the permissible speed range of the gas turbine 12 by mechanical and aerodynamic limits is limited, of course, are set at this output of dynamic power P dyn limits. Before reaching these limits, the gas turbine speed n mech must be stabilized with a sufficient safety margin.
  • the mechanical speed n mech for example, first with a high gradient, which is greater than the power frequency change, up to a first limit that still has a relatively small margin to the design limits of the gas turbine 12 can be reduced. After reaching this first limit, the speed n mech of the gas turbine 12 with a reduced gradient, for example, is smaller than that of the mains frequency change, be further changed. According to this reduced gradient, dynamic power P dyn can still be delivered to the network 21 until a second limit is reached. This second limit represents the minimum distance to the design limits of the gas turbine 12, which is to be maintained in order to ensure safe operation. Since the design limits include both mechanical limits and aerodynamic limits, the limits may be functions of the operating conditions of the gas turbine 12, in particular the mechanical speed n mech , the aerodynamic speed and of pressures or pressure conditions.
  • the ratio between change in mechanical speed n mech and line frequency change may be selected as a function of the distance from the actual mechanical speed n mech of the gas turbine 12 and the design limits. The ratio approaches zero when the mechanical speed n mech approaches the minimum distance to the design limits of the gas turbine 12.
  • the gas turbine 12 can be switched back to the optimum one independently of the value of the grid frequency F by the electrical decoupling mechanical speed n mech be driven.
  • the shaft train is accelerated or decelerated with a small gradient.
  • the gradient is sufficiently small to choose so that the required for acceleration dynamic power P dyn has no significant reduction in the power output to the network 21 result.
  • the gradient should be chosen such that only a maximum of about 5% of the gas turbine power is used as the dynamic power P dyn for acceleration.
  • the proportion is even less than 3% to keep. In practice, a share of less than 1% is sufficient.

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  • Engineering & Computer Science (AREA)
  • Power Engineering (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Control Of Eletrric Generators (AREA)
  • Control Of Turbines (AREA)
  • Supply And Distribution Of Alternating Current (AREA)

Claims (17)

  1. Procédé de conduite d'une centrale électrique (10) qui présente une ligne de turbine (11) constituée d'une turbine à gaz (12) et d'un générateur (18) entraîné directement par la turbine à gaz (12), produisant du courant alternatif à une fréquence de fonctionnement et dont la sortie est raccordée à un réseau (21) à fréquence (F) prédéterminée,
    un dispositif électronique de découplage (27) étant disposé entre le générateur (18) et le réseau (21) et découplant la fréquence de fonctionnement de la fréquence (F) du réseau,
    caractérisé en ce que
    au cas où surviennent des événements de sur-fréquence ou de sous-fréquence de courte durée sur le réseau (21), de l'énergie de rotation de la ligne de turbine (11) est libérée ou absorbée pour soutenir la fréquence par régulation de la vitesse de rotation mécanique (nmech) de la turbine à gaz (12).
  2. Procédé selon la revendication 1, caractérisé en ce que lorsque le réseau (21) est en sous-fréquence, la vitesse de rotation mécanique (nmech) de la turbine à gaz (12) est abaissée plus fort ou moins fort que la fréquence du réseau.
  3. Procédé selon la revendication 1, caractérisé en ce qu'en cas de sur-fréquence du réseau (21), la vitesse de rotation mécanique (nmech) de la turbine à gaz (12) est relevée plus fort ou moins fort que la fréquence (F) du réseau.
  4. Procédé selon l'une des revendications 1 à 3, caractérisé en ce qu'il utilise une turbine à gaz (12) dont la puissance est supérieure à 100 MW et comme dispositif électronique de découplage (27) un convertisseur de fréquences qui présente la forme d'un convertisseur matriciel.
  5. Procédé selon l'une des revendications 1 à 4, caractérisé en ce que la fréquence de fonctionnement est nettement différente de la fréquence du réseau ou d'une deuxième fréquence de fonctionnement.
  6. Procédé selon la revendication 5, caractérisé en ce que le convertisseur matriciel comporte plusieurs commutateurs (32) bidirectionnels asservis disposés en une matrice (m x n), qui relie sélectivement m entrées à n sorties sous la commande d'un régulateur (31), m étant supérieur à n, des premiers moyens (34) de détermination du signe des courants dans les entrées et des deuxièmes moyens (33) de détermination du signe des tensions entre les entrées étant prévus, les premiers et les deuxièmes moyens (34 ou 33) étant reliés au régulateur (31) par des conducteurs de signalisation (38).
  7. Procédé selon l'une des revendications 1 à 6, caractérisé en ce que la turbine à gaz (12) découplée de la fréquence du réseau tourne à une vitesse de rotation mécanique plus élevée pour, en cas d'événement de sous-fréquence, pouvoir délivrer une énergie cinétique supplémentaire au réseau (21) sous la forme d'une puissance électrique à partir de la ligne d'arbre (19).
  8. Procédé selon l'une des revendications 1 à 6, caractérisé en ce que la turbine à gaz (12) découplée de la fréquence du réseau tourne à une vitesse de rotation mécanique plus basse pour, en cas d'événement de sur-fréquence, pouvoir reprendre de l'énergie sur le réseau (21).
  9. Procédé selon l'une des revendications 1 à 8, caractérisé en ce que le gradient de vitesse de rotation est régulé pour prélever une énergie cinétique prédéterminée de la ligne d'arbre (19) et l'injecter sur le réseau (21) sous la forme de puissance électrique.
  10. Procédé selon la revendication 1, caractérisé en ce que la vitesse de rotation de la ligne d'arbre (19) est régulée dans un rapport fixe par rapport aux modifications de la fréquence du réseau.
  11. Procédé selon la revendication 1, caractérisé en ce qu'en cas de modification de la fréquence du réseau (21), la vitesse de rotation mécanique (nmech) de la turbine à gaz (12) est modifiée jusqu'à une première limite dans un premier rapport à la modification de la fréquence (F) du réseau, est modifiée à un deuxième rapport à la modification de la fréquence (F) du réseau entre la première limite et une deuxième limite et est maintenue constante et indépendante de la fréquence (F) du réseau à partir de la deuxième limite.
  12. Procédé selon la revendication 10, caractérisé en ce qu'au moins l'une des limites est une fonction de la vitesse de rotation aérodynamique de la turbine à gaz (12).
  13. Procédé selon l'une des revendications 1 à 12, caractérisé en ce que le gradient de la modification de la vitesse de rotation mécanique de la turbine à gaz (12) est limité.
  14. Procédé selon l'une des revendications 1 à 13, caractérisé en ce qu'après un événement de sur-fréquence ou de sous-fréquence, la vitesse de rotation mécanique (nmech) de la turbine à gaz est régulée à un petit gradient de vitesse de rotation pour être ramenée au point de fonctionnement optimum.
  15. Procédé selon l'une des revendications 1 à 13, caractérisé en ce qu'une pré-commande de la ou des soupapes de régulation de combustible a lieu en fonction du gradient de variation de la vitesse de rotation mécanique de la turbine à gaz (12).
  16. Procédé selon l'une des revendications 1 à 15, caractérisé en ce qu'en cas d'événement de sous-fréquence ou de sur-fréquence sur le réseau (21), la régulation (39) ne réagit qu'après que les modifications de fréquence ont dépassé une bande morte disposée autour de la fréquence du réseau.
  17. Procédé selon l'une des revendications 1 à 15, caractérisé en ce qu'en cas d'événement de sous-fréquence ou de sur-fréquence sur le réseau (21), la régulation (39) ne réagit qu'après que les modifications de fréquence par rapport à une valeur moyenne glissante de la fréquence du réseau ont dépassé une bande morte prédéterminée.
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PCT/EP2008/051617 WO2008098902A1 (fr) 2007-02-14 2008-02-11 Procédé de fonctionnement d'une centrale électrique

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JP2013192451A (ja) 2013-09-26
CN101657963B (zh) 2012-03-21
JP2010518320A (ja) 2010-05-27
DE102007007913A1 (de) 2008-08-21
CN101657963A (zh) 2010-02-24
US20100032964A1 (en) 2010-02-11
ATE496422T1 (de) 2011-02-15
EP2118997A1 (fr) 2009-11-18
DE502008002385D1 (de) 2011-03-03
JP5295978B2 (ja) 2013-09-18
US8796874B2 (en) 2014-08-05
JP5774058B2 (ja) 2015-09-02

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